CN105392958A - Downhole tool and method to boost fluid pressure and annular velocity - Google Patents
Downhole tool and method to boost fluid pressure and annular velocity Download PDFInfo
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- CN105392958A CN105392958A CN201380077221.2A CN201380077221A CN105392958A CN 105392958 A CN105392958 A CN 105392958A CN 201380077221 A CN201380077221 A CN 201380077221A CN 105392958 A CN105392958 A CN 105392958A
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- 239000012530 fluid Substances 0.000 title claims abstract description 76
- 238000000034 method Methods 0.000 title claims description 25
- 238000005553 drilling Methods 0.000 claims description 18
- 230000007246 mechanism Effects 0.000 claims description 16
- 230000004044 response Effects 0.000 claims description 14
- 230000000712 assembly Effects 0.000 claims description 7
- 238000000429 assembly Methods 0.000 claims description 7
- 238000005728 strengthening Methods 0.000 claims description 6
- 230000003068 static effect Effects 0.000 claims description 3
- 230000009969 flowable effect Effects 0.000 claims description 2
- 230000033001 locomotion Effects 0.000 description 5
- 238000010586 diagram Methods 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000000875 corresponding effect Effects 0.000 description 3
- 238000005755 formation reaction Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 230000001351 cycling effect Effects 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000032258 transport Effects 0.000 description 2
- 241000251468 Actinopterygii Species 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 229910010293 ceramic material Inorganic materials 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000002596 correlated effect Effects 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 239000002783 friction material Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000005461 lubrication Methods 0.000 description 1
- 230000007257 malfunction Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000007788 roughening Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/006—Mechanical motion converting means, e.g. reduction gearings
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/12—Combinations of two or more pumps
- F04D13/14—Combinations of two or more pumps the pumps being all of centrifugal type
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F15—FLUID-PRESSURE ACTUATORS; HYDRAULICS OR PNEUMATICS IN GENERAL
- F15B—SYSTEMS ACTING BY MEANS OF FLUIDS IN GENERAL; FLUID-PRESSURE ACTUATORS, e.g. SERVOMOTORS; DETAILS OF FLUID-PRESSURE SYSTEMS, NOT OTHERWISE PROVIDED FOR
- F15B3/00—Intensifiers or fluid-pressure converters, e.g. pressure exchangers; Conveying pressure from one fluid system to another, without contact between the fluids
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- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mechanical Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- General Engineering & Computer Science (AREA)
- Earth Drilling (AREA)
- Rotary Pumps (AREA)
- Details And Applications Of Rotary Liquid Pumps (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
Abstract
A disclosed embodiment of a downhole tool includes a pump that is powered by rotation of the drill string to increase fluid pressure during downhole circulation.
Description
Technical field
The disclosure is broadly directed to the circulation of drilling and well completion fluid, and relates more specifically to give additional energy to the downhole tool of these fluids in cycle period.
Background of invention
Bore hydrocarbon recovery well by rotary drill column, described drill string is roughly included in the assembly that lower end has multiple interconnection drill pipe section of drill bit and bottom hole assembly (" BHA ").When drilling well, drill bit produces landwaste and other chip.In downhole drill operation, fluid circulation is generally used for wellbore clean and solids transports, such as to remove landwaste and other chip.In general, circulation relates to along the drill string downward pumping fluid slush pump of ground (use) and by its annular space upwards between pumped back drill string and well bore wall.Fluid is referred to as annular velocity along the speed of annular space movement.Therefore, importantly monitor annular velocity and guarantee that suitable wellbore clean, solids transport and avoid the erosion of well bore wall.
Fluid annular velocity is adversely affected in many ways.Such as, in cycle period, in the circulating system, there is pressure drop due to the friction loss in pipeline and annular space and the hydrostatic pressure reduction between pipeline and annular space.Maximum pressure produces on slush pump manifold (standpipe pressure (" SPP ")) and minimum pressure to produce on fluid circuit (atmospheric pressure of open loop or for management and control pressure operation apply choke pressure).Therefore, flow velocity is limited to maximum SPP.Therefore, in some instances, annular velocity may be not high to being enough to fully clean pit shaft.But, if cycle period fluid pressure increase a little, so SPP may reduce.Then, this will allow the increase of maximum pump speed, and it produces higher annular velocity.
Therefore, in view of foregoing, there is the demand to the method increasing fluid annular velocity in this area.
Accompanying drawing is sketched
Fig. 1 diagram is according to the circulating system for drill-well operation of particular exemplary embodiment of the present disclosure;
Fig. 2 A is the sectional view of the downhole tool according to particular exemplary embodiment of the present disclosure;
Fig. 2 B illustrates the sectional view of the gear ring of locating according to the inner surface of the turnbarrel along downhole tool of particular exemplary embodiment of the present disclosure;
Fig. 2 C is the graphics comprising the downhole tool of multiple skew clamping components according to particular exemplary embodiment of the present disclosure;
Fig. 2 D is the cross-sectional top view of the downhole tool obtained along the line 2D of Fig. 2 A;
Fig. 3 A illustrates the alternate embodiment according to the driving mechanism used in downhole tool of particular exemplary embodiment of the present disclosure; And
The three-dimensional appearance figure of the downhole tool of Fig. 3 B pictorial image 3A.
Detailed description of the invention
Illustrative embodiment of the present disclosure and correlation technique can be used in downhole tool being hereafter described to them, and therefore it allow higher fluid annular velocity at cycle period enhance fluid annular pressure.For simplicity's sake, all features of actual embodiment or method are not described in this manual.In addition, " exemplary " embodiment described herein refers to example of the present disclosure.Certainly by understanding in the exploitation of any this actual embodiment, the specific decision-making of much enforcement must be made and realize the specific objective of the developer changed with embodiment, such as the compatibility limited of being correlated with business relevant to system.In addition, may be complicated and consuming time by a kind of like this behavior of developing of understanding, but just benefit from the normal work to do of persons skilled in the art of the present disclosure.By from hereafter describe and accompanying drawing consideration in become the further aspect and advantage of more understanding various embodiment of the present disclosure and correlation technique.
As described in this article, exemplary of the present disclosure relates to a kind of online downhole tool, and it drives with driving pump mechanism by drill string rotating, and described pump machanism, at cycle period enhance fluid pressure, therefore allows the increase of annular velocity.One of downhole tool open embodiment comprises driving mechanism, and it comprises driven wheel and driving shaft to control the torque (that is, revolving force) produced by rotary drill column.As used herein, term " gear " refers to any rotating member widely, and it has surface peripherally, and described surface is configured to engage with the surface of the periphery along another rotating member.In the exemplary hereafter discussed, described gear can be conventional gears, and it has the multiple teeth being configured to engage to the corresponding multiple tooth on another revolving part component (or another gear or gear ring).But, a kind of like this gear alternately comprises the surface on the periphery of such as gear, described surface when not using the conventional tooth gear teeth with the respective surfaces friction engagement on another rotating member, make when not using tooth, the rotation of causes another rotation.Surface for being frictionally engaged each other can be endowed great friction coefficient, such as by making surface roughening or execute deposited friction material, such as rubber compound.In response to the rotation of drill string, driven wheel rotates that power (via applying torque) is sent to the driving shaft being coupled to pump machanism.Driving shaft rotates, then power is sent to pump assembly from driving shaft, with driving pump assembly, to strengthen the pressure of the fluid travelling across downhole tool in response to applied torque.These and other feature of the present disclosure hereafter will be described in further detail.
Fig. 1 diagram is according to the circulating system for drill-well operation of particular exemplary embodiment of the present disclosure.Well system 100 (such as, rotary-type) comprises the rig 102 be positioned on the ground 104 of pit shaft.Rig 102 provides support for drill string 108.The rotating disk 110 that drill string 108 is used in drilling well cylinder 112 penetrates subsurface formations.In this exemplary, the bottom hole assembly 120 that drill string 108 comprises kelly bar 116 (in upper part) and is positioned in the lower part of drill string 108.Bottom hole assembly 120 comprises drill collar 122, for the downhole tool 124 of enhance fluid pressure and drill bit 126.In addition, although not shown, bottom hole assembly 120 can comprise other downhole tool any amount of, such as, and such as measurement while drilling (MWD) instrument, well logging during (LWD) instrument etc.
During drill-well operation, drill string 108 and bottom hole assembly 120 are rotated by rotating disk 110 or top drive, understand except concrete teaching of the present disclosure as in this area.In other embodiments, such as in directed drilling application, drill bit is alternately rotated by the motor (not shown) being positioned at down-hole.Drill collar 122 can be used for gaining in weight to drill bit 126, and reinforces bottom hole assembly 120, therefore allows bottom hole assembly 120 that weight is transferred to drill bit 126.Therefore, this weight provided by drill collar 122 also assists drill bit 126 penetrated surface 104 and subsurface formations.
During drill-well operation, drilling fluid (being also referred to as " drilling mud ") can be pumped to drilling pipe (locating along drill string 108), through downhole tool 124 and down to drill bit 126 from mud pit 134 through flexible pipe 136 by slush pump 132.As described in this article, the exemplary of downhole tool 124 is for managing the rotation of drill string to provide power to pump machanism, and described pump machanism increases the pressure of fluid when fluid travels across downhole tool 124.Drilling fluid can then flow out from drill bit 126 and be back to ground (that is, circulating) through the annular space region 140 drill string 108 and pit shaft 112 side.Drilling fluid can then be back to mud pit 134, and wherein these fluids are filtered.Therefore, drilling fluid can cool drill bit 126 and provide the lubrication of drill bit 126 during drill-well operation.In addition, drilling fluid removes the landwaste of the subsurface formations formed by drill bit 126.
With reference to figure 2A, now in detail the particular exemplary embodiment of downhole tool 124 will be described.Fig. 2 A is the sectional view of the downhole tool 124 along drill string location.But alternatively, downhole tool 124 also can be used for, in other bottom hole assembly, wherein carrying out fluid circulation, such as, such as well completion assemblies.Downhole tool 124 comprises tool outer casing 141, and it defines the fluid course (being referred to as in " hole ") 142 extended through wherein herein, and in described fluid course, fluid (such as, drilling well or well completion fluid) can flow.Driving mechanism 144 is located along hole 142.For example, driving mechanism 144 comprises two driven wheel 146a and 146b, and it to be located and relative to driving shaft 148 just to mutually positioning along tool outer casing 141.Driving shaft 148 is operationally coupled to driven wheel 146a, b via location central gear 150 at its upper end.In this exemplary, with another gear (being referred to as " central gear " 150 in this article), driven wheel 146a, b engage that revolving force is transferred to driving shaft 148.
Pump machanism 152 is operationally coupled to driving shaft 148 to receive power via institute's torque that applies of being given by driving shaft 148.Then, pump machanism 152 uses the rotation of driving shaft 148 to carry out driving pump 152 to increase the pressure of the fluid travelling across downhole tool 124 thus, the wherein corresponding increase of fluid annular velocity.In specific embodiments, driving shaft 148 forms a part for pump machanism 152, and in other embodiments, driving shaft 148 can be and is not included in pump machanism 152, but another rotating mechanism being operationally coupled to pump machanism 152 thinks that pump 150 provides the independent assembly of power.In this exemplary, pump machanism 152 is multi-stage impeller assemblies, and it comprises multiple impeller plates 154 of the configuration that is one another in series.Alternatively, other pump machanism can be used, such as, such as turbine, jet pump or another kind of centrifugal pump.Centrifugal pump is advantageous particularly, because it can produce additional hydraulic, discharges some standpipe pressures, and still can use when online pump driver malfunction.
Still with reference to the exemplary of figure 2A, driving mechanism 144 also comprises the sleeve 156 of locating around tool outer casing 141.The external surface of sleeve 156 comprises one or more clamping components 158 to engage the wall of pit shaft 112, makes sleeve 156 keep static during tool outer casing 141 rotates during cycling.In particular exemplary embodiment, select the diameter of sleeve 156 make it in the deployment of bottom hole assembly 120 and recall the wall up/down vertical sliding motion of period along pit shaft 112, also stoped the rotation of sleeve 156 simultaneously when drill string 108 rotates.The internal diameter of sleeve pipe or pit shaft can be such as used to determine suitable diameter.
Mechanical sealing member 160 is positioned on the top and bottom of sleeve 156 around tool outer casing 141 to provide anti-fluid to leak to the protection the region around driven wheel 146a, b from annular space 140.Seal can be made up of such as metal, plastics or ceramic materials.Gear ring 162 is located along the inner surface of sleeve 156, as shown in Figure 2 B.Gear ring 162 comprises a series of teeth being fixed to sleeve 152 or being integrally formed with sleeve 152, and the tooth that described tooth is located with each periphery along driven wheel 146a, b engages.Driven wheel 146a, b each (such as using pin 164) are rotatably coupled to tool outer casing 141 around respective axle, therefore allow driven wheel 146a, b respectively to rotate on the axle of axle being parallel to tool outer casing 141 during drill string 108 rotates.Therefore, when drill string 108 (and tool outer casing 141) rotates while sleeve 156 clamps the wall of pit shaft 112, power is transferred to driving mechanism 144 from drill string 108 and thinks that pump machanism 152 provides power.Particularly, further describe below with reference to Fig. 1 to Fig. 2 D, the rotation of drill string 108 is by the angular velocity throw shell 141 identical with drill string 108.The rotation of tool outer casing 141 causes driven wheel 146a, 146b to roll along gear ring 162, wherein driven wheel 146a, 146b when being rotatably coupled to tool outer casing 141 around the corresponding rotation of their axle.Driven wheel 146a, 146b around the powered rotation rotating to be central gear 150 of their axle, its driving pump.
It should be noted that in the present embodiment, two driven wheels 146a, 146b just minimize or avoid any lateral force on driving shaft 148, that is, transverse to the axis of rotation of driving shaft 148 to mutually positioning help balanced side force relative to driving shaft 148.But should be appreciated that, other embodiment can use around driving shaft 148 circle spacing, and the driven wheel of the varying number engaged with central gear 150.The embodiment even with the single driven wheel be positioned between gear ring 162 and centre-driven gear 150 is feasible, even if cannot be provided the above-mentioned lateral force balance of multiple driven wheel by a kind of so single driven wheel embodiment.
As mentioned above, driven wheel 146a, b can adopt the form of detent mechanism, and wherein each gear is located along tool outer casing 141 and rotatably fixed and rotates with the respective gear shaft around described gear.As shown in Figure 2 A, driven wheel 146a, 146b respectively comprises the part extended out from tool outer casing 141 and the part extended to tool outer casing 141.The central gear 150 of driving shaft 148 is positioned between driven wheel 146a and 146b, and it comprises tooth, described tooth engages with the tooth of driven wheel 146a, b, and make during drill string 108 rotates, the revolving force produced is sent to driving shaft 148 from driven wheel 146a, b.
Also described above, the external surface of turnbarrel 156 comprises clamping components 158, and it engages the wall of pit shaft 112.The profile of clamping components 158 is designed such that it allows bottom hole 120 along the vertical movement (such as, using the weight of drill string) of pit shaft 112, also prevents the in rotary moving of sleeve 156 simultaneously.Although not shown, in specific embodiments, clamping components 158 can be the fish plate be arranged on semielliptic spring, and described semielliptic spring outwards applies power, makes to maintain between the wall of plate and sleeve pipe or pit shaft to contact.Semielliptic spring can be selected to be applied to power required in any given application, and those skilled in the art as described in this article will understand.Alternatively, casing scraper or other similar device can be used for replacing spring to guarantee that clamping components is held against wall and fixes.
In addition, clamping components 158 can be constructed, although make the wall intimate contact of turnbarrel and pit shaft 112, still maintains the annular flow path of annular space 140, makes to carry out cycling.For realizing this point, clamping components 158 can adopt various ways, includes but not limited to tilt as shown in Figure 1 scraper or multiple offset components as shown in FIG. 2 C, and it forms the fluid course around clamping components 158.Fig. 2 C is the graphics of downhole tool 124, and it comprises multiple exemplary offset clamping components 158.
In order to illustrate the fluid flowing of cycle period, provide Fig. 2 D, the cross-sectional top view of the downhole tool 124 that its diagram obtains along the line 2D of Fig. 2 A.At this, clamping components 158 is engaged to the wall 113 of pit shaft 112, makes sleeve 156 rotatably fixing (that is, it cannot rotate).Wall 113 can be sleeve pipe, bushing pipe or surface of stratum, because the disclosure can be used in cased well and open hole application.During exemplary cycle operation, fluid is pumped down through internal flow region 166 (hole 142), and enter pump machanism 152 through driving mechanism 144, increase the pressure of fluid thus, it provides the annular velocity of increase.Subsequently, fluid extrudes from the bottom (as shown around sleeve 156) of bottom hole assembly 120 and upwards pushes back annular space 140.
Since described the various assemblies of exemplary downhole tool 124, the illustrative methods utilizing downhole tool 124 is so described with reference to Fig. 1 to Fig. 2 D.During drill-well operation, such as, drill string 108 is lowered in pit shaft 112, until arrive desired locations.When drill bit 126 bores stratum, clamping components 158 allows sleeve 156 along the wall vertical sliding motion of pit shaft 112.But, when drill string 108 is by rotation, clamping components 158 joined wall, therefore fixed muffle 156.Subsequently, when fluid L (Fig. 2 A) flows through drill string 108 (by slush pump 132 pumping) and passes internal flow region 166, drill string 108 is rotated, and tool outer casing 141 is also rotated, therefore forms revolving force.When tool outer casing 141 rotates, driven wheel 146a, b start when its tooth coordinates with the rotatable fixed gear ring 162 of sleeve 156 to rotate along pin 164.
When driven wheel 146a, b continue to rotate, revolving force is transferred to the central gear 150 of driving shaft 148 by them, therefore causes it to rotate.When driving shaft 148 rotates, revolving force is then transferred to pump machanism 152 by it, make impeller plate 154 rotate thus, described impeller plate 154 flows through the pressure increasing fluid L during each plate 154 at fluid L, will understand as benefited from persons skilled in the art of the present disclosure.Fluid L then flows through the support of bearing 155 of the lower end being coupled to pump machanism 152.It is three or four radial arm (not shown) that the support of bearing 155 comprises, and it stretches out (similar spoke), and multiple runner 157 is formed, and described runner 157 allows fluid L to flow through wherein.Fluid L is then pressed down through drill collar 122, extrudes drill bit 126, presses along annular space 140 (around sleeve 156) is upper and is pushed back ground 104 for further circular treatment.Therefore, the rotation of drill string 108 is for generation of revolving force, and it controls by downhole tool 124 pressure increasing circulation of fluid, therefore allows higher annular velocity.In addition, because sleeve 156 allows the vertical movement of bottom hole assembly 120, therefore bottom hole assembly 120 can move up or down along pit shaft 112 according to expectation, simultaneously also enhance fluid pressure.
Fig. 3 A illustrates the alternate embodiment according to the driving mechanism 144 of particular exemplary embodiment of the present disclosure.In the present embodiment, sleeve is not used; But use the first frictional force transfer element 168a and the second frictional force transfer element 168b to replace driven wheel 146a, b respectively.Mechanical sealing member 170 is located around the first traction elements 168a and the second traction elements 168b to stop fluid to leak.As mentioned above, the first frictional force transfer element and the second frictional force transfer element use pin 164 to be fixed to tool outer casing 141.Therefore, a part of the first frictional force transfer element 168a and the second frictional force transfer element 168b extends out from tool outer casing 141, and another part extends in tool outer casing 141.Selection, makes between frictional force transfer element 168a, b and well bore wall, provide the frictional force of q.s to form revolving force from transfer element 168a across the diameter to 168b.Because frictional force transfer element 168a, b are around tool outer casing 141 interval, so fluid is allowed to flow over them in cycle period, as shown in Figure 3 B, the three-dimensional appearance figure of its diagram downhole tool 124.
The part of the first frictional force transfer element 168a extended out from tool outer casing 141 and the second frictional force transfer element 168b engages the wall of pit shaft 112.In this example, central gear 150 tooth or also can be that can comprise along its external diameter is enough to shift the friction-type surface of revolving force.When drill string 108 is by rotation, the first frictional force transfer element 168a and the second frictional force transfer element 168b starts to rotate along pin 164, therefore forms the revolving force being transferred to central gear 150 as described above.Then, pump machanism 152 is provided power as mentioned above.Frictional force transfer element 168a, b can be such as polymer or metal friction ball or some other suitable frictional force transfer elements.In addition, fluid flows through the downhole tool 124 of Fig. 3 A to Fig. 3 B, to flow and upwards to flow back to annular space 140 identical with described in previous example around the first frictional force transfer element 168a with the second frictional force transfer element 168b.Therefore, the rotation of drill string 108 is for generation of revolving force, and described revolving force controls by downhole tool 124 pressure increasing fluid.
Therefore, by using the disclosure, the power of management drill string rotating is with driving pump mechanism, and described pump machanism increases the pressure of circulation of fluid, therefore allows higher annular velocity.Therefore, the higher pump speed exceeding and supplied by Conventional mud pump is provided.In addition, by using the disclosure, standpipe pressure can reduce, and therefore increases the overall presure drop in the circulating system, allows slush pump with more rapid rate operation thus.The fluid pressure of this increase can be used for increasing maximum pump speed and annular velocity such as to strengthen wellbore clear during flooding operation while drilling well and casing clean.
The exemplary of downhole tool described herein is particularly useful for such as flooding operation, thus against sleeve pipe or bushing pipe setting tool.Alternatively, downhole tool can be used in drill-well operation, and instrument is upwards fixed against lithostratigraphy thus.In a rear embodiment, downhole tool can orientate the bottom of next-door neighbour's drill string as to maximize the increase of annular space water flow velocity, such as, and such as distance about 95 feet of drill bit.
Exemplary of the present disclosure provides a kind of instrument for strengthening downhole fluid pressure, and instrument comprises: tool outer casing, and it is configured to be coupled to drill string, and tool outer casing defines fluid course; Sleeve, it is rotatably located around tool outer casing, and sleeve comprises one or more clamping components that being configured in the outer part of sleeve clamps well bore wall; Driving shaft, it passes tool outer casing and has central gear; At least one driven wheel, it is rotatably coupled to sleeve, and interior part and the central gear of at least one driven wheel and sleeve engage; And pump machanism, it is coupled to driving shaft to receive the power given by the rotation of driving shaft, and pump is configured to increase the fluid pressure in runner.In another embodiment, pump comprises multi-stage impeller assembly.In still another embodiment, at least one driven wheel rotatably couples around the axle of the axle being parallel to tool outer casing.
In another embodiment of the present disclosure, instrument comprises multiple teeth of part in turnbarrel further; Multiple teeth at least one driven wheel; With the multiple teeth on the central gear of driving shaft, the tooth wherein at least one driven wheel with in turnbarrel part tooth and central gear on tooth engage.In still another embodiment, at least one driven wheel comprises the multiple driven wheels around the driving shaft circle spacing.In another embodiment, instrument comprises the multiple offset components defining fluid course around one or more clamping components further.
Another exemplary of the present disclosure provides a kind of instrument for strengthening downhole fluid pressure, and instrument comprises: tool outer casing, and it rotates relative to well bore wall, and tool outer casing defines the flowable runner of wherein fluid; Driven wheel, it comprises and has the part that extends out from tool outer casing and extend to the first frictional force transfer element of the part tool outer casing and have the part extended out from tool outer casing and the second frictional force transfer element extending to the part tool outer casing, and wherein the part clamping well bore wall extended out from tool outer casing of the first frictional force transfer element and the second frictional force transfer element is to be formed revolving force when tool outer casing rotates; Driving shaft, it is operationally coupled to the first frictional force transfer element and the second frictional force transfer element, thus during tool outer casing rotates, revolving force is transferred to driving shaft by the first frictional force transfer element and the second frictional force transfer element, causes the rotation of driving shaft thus; And pump machanism, it is located along runner and is operationally coupled to driving shaft to receive the revolving force given by driving shaft thus, and therefore driving pump mechanism is to strengthen the pressure travelling across the fluid of runner.
In an alternate embodiment, the first frictional force transfer element and the second frictional force transfer element are friction balls.In still another embodiment, the first frictional force transfer element and the second frictional force transfer element rotate during tool outer casing rotates on the axle of axle being parallel to tool outer casing.In any above-mentioned embodiment, pit shaft can add sleeve pipe.In addition, in described same example embodiment, instrument forms the part of drilling well or well completion assemblies.
Illustrative methods of the present disclosure provides a kind of method for strengthening the fluid pressure in pit shaft, and method comprises the desired locations be positioned at by downhole tool along pit shaft, and fluid travels across the runner of downhole tool thus; Downhole tool is rotated relative to apparent surface to produce revolving force; Driving pump mechanism is come to strengthen the pressure of the fluid travelling across downhole tool thus with utilizing revolving force.Another method comprises the annular velocity increasing fluid in response to supercharging further.In another method, downhole tool is rotated and comprises to produce revolving force the turnbarrel clamping apparent surface used around downhole tool location further; When turnbarrel keeps static, downhole tool is rotated; Rotation in response to downhole tool makes the driven wheel being operationally coupled to turnbarrel rotate; With the rotation in response to driven wheel, the driving shaft being operationally coupled to driven wheel is rotated.In another embodiment, driving pump mechanism comprises the rotary actuation pump machanism in response to driving shaft further.
In another method, downhole tool is rotated and comprises to produce revolving force the frictional force transfer element clamping apparent surface used along downhole tool location further; Downhole tool is rotated; Rotation in response to downhole tool makes frictional force transfer element rotate; With the rotation in response to frictional force transfer element, the driving shaft being operationally coupled to frictional force transfer element is rotated.Another method comprise further fluid extruded downhole tool and upper pressure through the annular space formed downhole tool and apparent surface.In another embodiment, clamp apparent surface and comprise grip sleeve, bushing pipe or surface of stratum further.In still another embodiment, the desired locations be positioned at by downhole tool along pit shaft comprises part downhole tool being deployed as drilling well or well completion assemblies further.
Above-mentioned openly can in various example repeat reference numerals and/or letter.Thisly repeat to be object in order to simplify and understand and itself relation not between the various embodiment discussed of regulation and/or structure.In addition, space relative terms, such as " below ", " below ", D score, " top ", " on " and similar terms can conveniently be described in herein for describing the relation of an element or feature and another element or feature as illustrated in the drawing.The difference except the orientation described in figure that space relative terms is intended to contain the equipment used or in operation is directed.Such as, if the equipment in figure is reversed, the element being so described as be in other element or feature " below " or " below " then will be oriented in other element or feature " top ".Therefore, exemplary term " below " can contain above and below orientation.Equipment can otherwise directed (half-twist or other directed), and space used herein relative descriptors can correspondingly be explained equally.
Although shown and described various embodiment and method, the disclosure has been not limited to these embodiments and method, and will be understood to include all modifications as understood by those skilled in the art and variation.Therefore, should be appreciated that the disclosure is not intended to be limited to particular forms disclosed.But intention covering belongs to all modifications example, equivalence example and alternative in the spirit and scope of the present disclosure as defined by claim of enclosing.
Claims (19)
1., for strengthening an instrument for downhole fluid pressure, described instrument comprises:
Tool outer casing, it is configured to be coupled to drill string, and described tool outer casing defines fluid course;
Sleeve, it is rotatably located around described tool outer casing, and described sleeve comprises one or more clamping components that being configured in the outer part of described sleeve clamps well bore wall;
Driving shaft, it passes described tool outer casing and has central gear;
At least one driven wheel, it is rotatably coupled to described sleeve, and interior part and the described central gear of at least one driven wheel described and described sleeve engage; With
Pump machanism, it is coupled to described driving shaft to receive the power given by the rotation of described driving shaft, and described pump is configured to increase the fluid pressure in described runner.
2. instrument according to claim 1, wherein said pump comprises multi-stage impeller assembly.
3. instrument according to claim 1, at least one driven wheel wherein said rotatably couples around the axle of the axle being parallel to described tool outer casing.
4. instrument according to claim 1, it comprises further:
Along multiple teeth of the described interior part of described turnbarrel;
Multiple teeth at least one driven wheel described; With
Multiple teeth on the described central gear of described driving shaft, the described tooth on the described tooth of the described tooth at least one driven wheel wherein said and the described interior part along described turnbarrel and described central gear engages.
5. instrument according to claim 4, at least one driven wheel wherein said comprises the multiple driven wheels around the described driving shaft circle spacing.
6. instrument according to claim 1, it comprises the multiple offset components defining fluid course around described one or more clamping components further.
7., for strengthening an instrument for downhole fluid pressure, described instrument comprises:
Tool outer casing, it rotates relative to well bore wall, and described tool outer casing defines the flowable runner of wherein fluid;
Driven wheel, it comprises:
First frictional force transfer element, it has the part extended out from described tool outer casing and the part extended to described tool outer casing; With
Second frictional force transfer element, it has the part that extends out from described tool outer casing and extends to the part described tool outer casing, and the described part extended out from described tool outer casing of wherein said first frictional force transfer element and described second frictional force transfer element clamps described well bore wall to be formed revolving force when described tool outer casing rotates;
Driving shaft, it is operationally coupled to described first frictional force transfer element and described second frictional force transfer element, thus during described tool outer casing rotates, described revolving force is transferred to described driving shaft by described first frictional force transfer element and described second frictional force transfer element, causes the rotation of described driving shaft thus; With
Pump machanism, it is located along described runner and is operationally coupled to described driving shaft to receive the described revolving force given by described driving shaft thus, therefore drives described pump machanism to strengthen the pressure travelling across the fluid of described runner.
8. instrument according to claim 7, wherein said first frictional force transfer element and described second frictional force transfer element are friction balls.
9. instrument according to claim 7, wherein said first frictional force transfer element and described second frictional force transfer element rotate during described tool outer casing rotates on the axle of axle being parallel to described tool outer casing.
10. the instrument according to claim 1 or 7, wherein said well bore wall adds sleeve pipe.
11. instruments according to claim 1 or 7, wherein said instrument forms the part of drilling well or well completion assemblies.
12. 1 kinds for strengthening the method for the fluid pressure in pit shaft, described method comprises:
Downhole tool is positioned at the desired locations along described pit shaft, fluid travels across the runner of described downhole tool thus;
Described downhole tool is rotated relative to apparent surface to produce revolving force; With
Described revolving force is utilized to come driving pump mechanism to strengthen the pressure of the described fluid travelling across described downhole tool thus.
13. methods according to claim 12, it comprises the annular velocity increasing described fluid in response to described supercharging further.
14. methods according to claim 12, wherein make described downhole tool rotate and comprise further to produce described revolving force:
The turnbarrel of locating around described downhole tool is used to clamp described apparent surface;
When described turnbarrel keeps static, described downhole tool is rotated;
Rotation in response to described downhole tool makes the driven wheel being operationally coupled to described turnbarrel rotate; With
Rotation in response to described driven wheel makes the driving shaft being operationally coupled to described driven wheel rotate.
15. methods according to claim 14, pump machanism described in the described rotary actuation wherein driving described pump machanism to comprise in response to described driving shaft further.
16. methods according to claim 12, wherein make described downhole tool rotate and comprise further to produce described revolving force:
The frictional force transfer element of locating along described downhole tool is used to clamp described apparent surface;
Described downhole tool is rotated;
Rotation in response to described downhole tool makes described frictional force transfer element rotate; With
Rotation in response to described frictional force transfer element makes the driving shaft being operationally coupled to described frictional force transfer element rotate.
17. methods according to claim 12, its comprise further described fluid extruded described downhole tool and upper pressure through the annular space formed described downhole tool and described apparent surface.
18. methods according to claim 13 or 16, wherein clamp described apparent surface and comprise grip sleeve, bushing pipe or surface of stratum further.
19. methods according to claim 12, wherein by described downhole tool, the described desired locations be positioned at along described pit shaft comprises the part described downhole tool being deployed as drilling well or well completion assemblies further.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2013/050731 WO2015009289A1 (en) | 2013-07-16 | 2013-07-16 | Downhole tool and method to boost fluid pressure and annular velocity |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN105392958A true CN105392958A (en) | 2016-03-09 |
| CN105392958B CN105392958B (en) | 2017-09-05 |
Family
ID=52346585
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201380077221.2A Expired - Fee Related CN105392958B (en) | 2013-07-16 | 2013-07-16 | Strengthen the downhole tool and method of Fluid pressure and annular velocity |
Country Status (11)
| Country | Link |
|---|---|
| US (1) | US10246957B2 (en) |
| CN (1) | CN105392958B (en) |
| AU (1) | AU2013394383B2 (en) |
| BR (1) | BR112015030222A2 (en) |
| CA (1) | CA2912971C (en) |
| DE (1) | DE112013007241T5 (en) |
| GB (1) | GB2530925B (en) |
| MX (1) | MX367162B (en) |
| NO (1) | NO347118B1 (en) |
| RU (1) | RU2622417C1 (en) |
| WO (1) | WO2015009289A1 (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108561092A (en) * | 2018-04-22 | 2018-09-21 | 中国石油大学(华东) | Shunt nipple |
| CN108979570A (en) * | 2018-07-15 | 2018-12-11 | 西南石油大学 | A kind of shaft bottom drilling fluid energizer |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2016118777A1 (en) * | 2015-01-22 | 2016-07-28 | Thoratec Corporation | Reduced rotational mass motor assembly for catheter pump |
| CN113167059B (en) * | 2018-10-12 | 2023-05-23 | 贝克休斯控股有限责任公司 | Dual ESP with selectable pumps |
| CN110984916B (en) * | 2020-02-04 | 2022-05-13 | 温州大学 | Turbine-driven thermal mass spraying and melting type flow guide wax scraping device |
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- 2013-07-16 WO PCT/US2013/050731 patent/WO2015009289A1/en active Application Filing
- 2013-07-16 CA CA2912971A patent/CA2912971C/en active Active
- 2013-07-16 MX MX2015017230A patent/MX367162B/en active IP Right Grant
- 2013-07-16 AU AU2013394383A patent/AU2013394383B2/en not_active Ceased
- 2013-07-16 GB GB1520161.9A patent/GB2530925B/en active Active
- 2013-07-16 CN CN201380077221.2A patent/CN105392958B/en not_active Expired - Fee Related
- 2013-07-16 NO NO20151766A patent/NO347118B1/en unknown
- 2013-07-16 RU RU2015152167A patent/RU2622417C1/en not_active IP Right Cessation
- 2013-07-16 US US14/890,625 patent/US10246957B2/en active Active
- 2013-07-16 DE DE112013007241.6T patent/DE112013007241T5/en not_active Withdrawn
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Also Published As
| Publication number | Publication date |
|---|---|
| US10246957B2 (en) | 2019-04-02 |
| CN105392958B (en) | 2017-09-05 |
| WO2015009289A1 (en) | 2015-01-22 |
| NO20151766A1 (en) | 2015-12-22 |
| AU2013394383A1 (en) | 2015-12-03 |
| RU2622417C1 (en) | 2017-06-15 |
| CA2912971C (en) | 2017-10-10 |
| CA2912971A1 (en) | 2015-01-22 |
| NO347118B1 (en) | 2023-05-15 |
| GB201520161D0 (en) | 2015-12-30 |
| GB2530925A (en) | 2016-04-06 |
| GB2530925B (en) | 2020-01-29 |
| MX2015017230A (en) | 2016-07-20 |
| US20160123098A1 (en) | 2016-05-05 |
| MX367162B (en) | 2019-08-07 |
| DE112013007241T5 (en) | 2016-04-07 |
| BR112015030222A2 (en) | 2017-07-25 |
| AU2013394383B2 (en) | 2016-08-11 |
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